DECISIONS. (Text with EEA relevance) (2014/738/EU)

Transcription

1 L 307/38 DECISIONS COMMISSION IMPLEMTING DECISION of 9 October 2014 establishing best available techniques (BAT) conclusions, under Directive 2010/75/EU of the European Parliament and of the Council on industrial emissions, for the refining of mineral oil and gas (notified under document C(2014) 7155) (Text with EEA relevance) (2014/738/EU) THE EUROPEAN COMMISSION, Having regard to the Treaty on the Functioning of the European Union, Having regard to Directive 2010/75/EU of the European Parliament and of the Council of 24 November 2010 on industrial emissions (integrated pollution prevention and control) ( 1 ), and in particular Article 13(5) thereof, Whereas: (1) Article 13(1) of Directive 2010/75/EU requires the Commission to organise an exchange of information on industrial emissions between it and Member States, the industries concerned and non-governmental organisations promoting environmental protection in order to facilitate the drawing up of best available techniques (BAT) reference documents as defined in Article 3(11) of that Directive. (2) In accordance with Article 13(2) of Directive 2010/75/EU, the exchange of information is to address the performance of installations and techniques in terms of emissions, expressed as short- and long-term averages, where appropriate, and the associated reference conditions, consumption and nature of raw materials, water consumption, use of energy and generation of waste and the techniques used, associated monitoring, cross-media effects, economic and technical viability and developments therein and best available techniques and emerging techniques identified after considering the issues mentioned in points (a) and (b) of Article 13(2) of that Directive. (3) BAT conclusions as defined in Article 3(12) of Directive 2010/75/EU are the key element of BAT reference documents and lay down the conclusions on best available techniques, their description, information to assess their applicability, the emission levels associated with the best available techniques, associated monitoring, associated consumption levels and, where appropriate, relevant site remediation measures. (4) In accordance with Article 14(3) of Directive 2010/75/EU, BAT conclusions are to be the reference for setting permit conditions for installations covered by Chapter II of that Directive. (5) Article 15(3) of Directive 2010/75/EU requires the competent authority to set emission limit values that ensure that, under normal operating conditions, emissions do not exceed the emission levels associated with the best available techniques as laid down in the decisions on BAT conclusions referred to in Article 13(5) of Directive 2010/75/EU. (6) Article 15(4) of Directive 2010/75/EU provides for derogations from the requirement laid down in Article 15(3) only where the costs associated with the achievement of the emission levels associated with the BAT disproportionately outweigh the environmental benefits due to the geographical location, the local environmental conditions or the technical characteristics of the installation concerned. (7) Article 16(1) of Directive 2010/75/EU provides that the monitoring requirements in the permit referred to in point (c) of Article 14(1) of the Directive are to be based on the conclusions on monitoring as described in the BAT conclusions. ( 1 ) OJ L 334, , p. 17.

2 L 307/39 (8) In accordance with Article 21(3) of Directive 2010/75/EU, within 4 years of publication of decisions on BAT conclusions, the competent authority is to reconsider and, if necessary, update all the permit conditions and ensure that the installation complies with those permit conditions. (9) The Commission established a forum composed of representatives of Member States, the industries concerned and non-governmental organisations promoting environmental protection by Decision of 16 May 2011 establishing a forum for the exchange of information pursuant to Article 13 of Directive 2010/75/EU on industrial emissions ( 1 ). (10) In accordance with Article 13(4) of Directive 2010/75/EU, the Commission obtained the opinion of the forum, established by Decision of 16 May 2011, on the proposed content of the BAT reference document for the refining of mineral oil and gas on 20 September 2013 and made it publicly available. (11) The measures provided for in this Decision are in accordance with the opinion of the Committee established by Article 75(1) of Directive 2010/75/EU, HAS ADOPTED THIS DECISION: Article 1 The BAT conclusions for the refining of mineral oil and gas, as set out in the Annex, are adopted. This Decision is addressed to the Member States. Article 2 Done at Brussels, 9 October For the Commission Janez POTOČNIK Member of the Commission ( 1 ) OJ C 146, , p. 3.

3 L 307/40 ANNEX BAT CONCLUSIONS FOR THE REFINING OF MINERAL OIL AND GAS SCOPE GERAL CONSIDERATIONS Averaging periods and reference conditions for emissions to air Conversion of emissions concentration to reference oxygen level Averaging periods and reference conditions for emissions to water DEFINITIONS General BAT conclusions for the refining of mineral oil and gas Environmental management systems Energy efficiency Solid materials storage and handling Monitoring of emissions to air and key process parameters Operation of waste gas treatment systems Monitoring of emissions to water Emissions to water Waste generation and management Noise BAT conclusions for integrated refinery management BAT conclusions for the alkylation process Hydrofluoric acid alkylation process Sulphuric acid alkylation process BAT conclusions for base oil production processes BAT conclusions for the bitumen production process BAT conclusions for the fluid catalytic cracking process BAT conclusions for the catalytic reforming process BAT conclusions for the coking processes BAT conclusions for the desalting process BAT conclusions for the combustion units BAT conclusions for the etherification process BAT conclusions for the isomerisation process BAT conclusions for the natural gas refinery BAT conclusions for the distillation process BAT conclusions for the products treatment process... 69

4 L 307/ BAT conclusions for storage and handling processes BAT conclusions for visbreaking and other thermal processes BAT conclusions for waste gas sulphur treatment BAT conclusions for flares BAT conclusions for integrated emission management GLOSSARY Description of techniques for the prevention and control of emissions to air Dust Nitrogen oxides (NO X ) Sulphur oxides (SO X ) Combined techniques (SO x, NO x and dust) Carbon monoxide (CO) Volatile organic compounds (VOC) Other techniques Description of techniques for the prevention and control of emissions to water Waste water pretreatment Waste water treatment SCOPE These BAT conclusions cover certain industrial activities specified in Section 1.2 of Annex I to Directive 2010/75/EU, namely 1.2. Refining of mineral oil and gas. In particular, these BAT conclusions cover the following processes and activities: Activity Subactivities or processes included in activity Alkylation Base oil production Bitumen production Catalytic cracking Catalytic reforming Coking Cooling Desalting Combustion units for energy production All alkylation processes: hydrofluoric acid (HF), sulphuric acid (H 2 SO 4 ) and solid-acid Deasphalting, aromatic extraction, wax processing and lubricant oil hydrofinishing All techniques from storage to final product additives All types of catalytic cracking units such as fluid catalytic cracking Continuous, cyclic and semi-regenerative catalytic reforming Delayed and fluid coking processes. Coke calcination Cooling techniques applied in refineries Desalting of crude oil Combustion units burning refinery fuels, excluding units using only conventional or commercial fuels

5 L 307/42 Activity Subactivities or processes included in activity Etherification Gas separation Hydrogen consuming processes Hydrogen production Production of chemicals (e.g. alcohols and ethers such as MTBE, ETBE and TAME) used as motor fuels additives Separation of light fractions of the crude oil e.g. refinery fuel gas (RFG), liquefied petroleum gas (LPG) Hydrocracking, hydrorefining, hydrotreatments, hydroconversion, hydroprocessing and hydrogenation processes Partial oxidation, steam reforming, gas heated reforming and hydrogen purification Isomerisation Isomerisation of hydrocarbon compounds C 4, C 5 and C 6 Natural gas plants Polymerisation Primary distillation Product treatments Storage and handling of refinery materials Natural gas (NG) processing including liquefaction of NG Polymerisation, dimerisation and condensation Atmospheric and vacuum distillation Sweetening and final product treatments Storage, blending, loading and unloading of refinery materials Visbreaking and other thermal conversions Thermal treatments such as visbreaking or thermal gas oil process Waste gas treatment Waste water treatment Waste management Techniques to reduce or abate emissions to air Techniques to treat waste water prior to release Techniques to prevent or reduce the generation of waste These BAT conclusions do not address the following activities or processes: the exploration and production of crude oil and natural gas; the transportation of crude oil and natural gas; the marketing and distribution of products. Other reference documents which may be relevant for the activities covered by these BAT conclusions are the following: Reference document Common Waste Water and Waste Gas Treatment/Management Systems in the Chemical Sector (CWW) Subject Waste water management and treatment techniques Industrial Cooling Systems (ICS) Economics and Cross-media Effects (ECM) Cooling processes Economics and cross-media effects of techniques

6 L 307/43 Emissions from Storage (EFS) Energy Efficiency (E) Reference document Large Combustion Plants (LCP) Large Volume Inorganic Chemicals Ammonia, Acids and Fertilisers Industries (LVIC-AAF) Large Volume Organic Chemical Industry (LVOC) Waste Incineration (WI) Waste Treatment (WT) General Principles of Monitoring (MON) Subject Storage, blending, loading and unloading of refinery materials Energy efficiency and integrated refinery management Combustion of conventional and commercial fuels Steam reforming and hydrogen purification Etherification process (MTBE, ETBE and TAME production) Waste incineration Waste treatment Monitoring of emissions to air and water GERAL CONSIDERATIONS The techniques listed and described in these BAT conclusions are neither prescriptive nor exhaustive. Other techniques may be used that ensure at least an equivalent level of environmental protection. Unless otherwise stated, these BAT conclusions are generally applicable. Averaging periods and reference conditions for emissions to air Unless stated otherwise, emission levels associated with the best available techniques (BAT-AELs) for emissions to air given in these BAT conclusions refer to concentrations, expressed as mass of emitted substance per volume of waste gas under the following standard conditions: dry gas, temperature of 273,15 K, pressure of 101,3 kpa. For continuous measurements For periodic measurements BAT-AELs refer to monthly average values, which are the averages of all valid hourly average values measured over a period of one month BAT-AELs refer to the average value of three spot samples of at least 30 minutes each For combustion units, catalytic cracking processes, and waste gas sulphur recovery units, reference conditions for oxygen are shown in Table 1. Table 1 Reference conditions for BAT-AELs concerning emissions to air Activities Unit Oxygen reference conditions Combustion unit using liquid or gaseous fuels with the exception of gas turbines and engines mg/nm 3 3 % oxygen by volume Combustion unit using solid fuels mg/nm 3 6 % oxygen by volume

7 L 307/44 Activities Unit Oxygen reference conditions Gas turbines (including combined cycle gas turbines CCGT) and engines mg/nm 3 15 % oxygen by volume Catalytic cracking process (regenerator) mg/nm 3 3 % oxygen by volume Waste gas sulphur recovery unit ( 1 ) mg/nm 3 3 % oxygen by volume ( 1 ) In case of applying BAT 58. Conversion of emissions concentration to reference oxygen level The formula for calculating the emissions concentration at a reference oxygen level (see Table 1) is shown below. Where: E R (mg/nm 3 ): O R (vol %): E M (mg/nm 3 ): O M (vol %): E R ¼ 21 O R 21 O M E M emissions concentration referred to the reference oxygen level O R reference oxygen level emissions concentration referred to the measured oxygen level O M measured oxygen level. Averaging periods and reference conditions for emissions to water Unless stated otherwise, emission levels associated with the best available techniques (BAT-AELs) for emissions to water given in these BAT conclusions refer to values of concentration (mass of emitted substances per volume of water) expressed in mg/l. Unless stated otherwise, the averaging periods associated with the BAT-AELs are defined as follows: Daily average Yearly/Monthly average Average over a sampling period of 24 hours taken as a flow-proportional composite sample or, provided that sufficient flow stability is demonstrated, from a time-proportional sample Average of all daily averages obtained within a year/month, weighted according to the daily flows DEFINITIONS For the purpose of these BAT conclusions, the following definitions apply: Term used Definition Unit New unit Existing unit A segment/subpart of the installation in which a specific processing operation is conducted A unit first permitted on the site of the installation following the publication of these BAT conclusions or a complete replacement of a unit on the existing foundations of the installation following the publication of these BAT conclusions A unit which is not a new unit

8 L 307/45 Process off-gas Term used Definition The collected gas generated by a process which must be treated e.g. in an acid gas removal unit and a sulphur recovery unit (SRU) Flue-gas The exhaust gas exiting a unit after an oxidation step, generally combustion (e.g. regenerator, Claus unit) Tail gas Common name of the exhaust gas from an SRU (generally Claus process) VOC Volatile organic compounds as defined in Article 3(45) of Directive 2010/75/EU NMVOC VOC excluding methane Diffuse VOC emissions Non-channelled VOC emissions that are not released via specific emission points such as stacks. They can result from area sources (e.g. tanks) or point sources (e.g. pipe flanges) NO X expressed as NO 2 The sum of nitrogen oxide (NO) and nitrogen dioxide (NO 2 ) expressed as NO 2 SO X expressed as SO 2 The sum of sulphur dioxide (SO 2 ) and sulphur trioxide (SO 3 ) expressed as SO 2 H 2 S Hydrogen sulphide. Carbonyl sulphide and mercaptan are not included Hydrogen chloride expressed as HCl All gaseous chlorides expressed as HCl Hydrogen fluoride expressed as HF All gaseous fluorides expressed as HF FCC unit Fluid catalytic cracking: a conversion process for upgrading heavy hydrocarbons, using heat and a catalyst to break larger hydrocarbon molecules into lighter molecules SRU Sulphur recovery unit. See definition in Section Refinery fuel Solid, liquid or gaseous combustible material from the distillation and conversion steps of the refining of crude oil. Examples are refinery fuel gas (RFG), syngas and refinery oils, pet coke RFG Refinery fuel gas: off-gases from distillation or conversion units used as a fuel Combustion unit Unit burning refinery fuels alone or with other fuels for the production of energy at the refinery site, such as boilers (except CO boilers), furnaces, and gas turbines. Continuous measurement Measurement using an automated measuring system (AMS) or a continuous emission monitoring system (CEMS) permanently installed on site Periodic measurement Determination of a measurand at specified time intervals using manual or automated reference methods Indirect monitoring of emissions to air Estimation of the emissions concentration in the flue-gas of a pollutant obtained through an appropriate combination of measurements of surrogate parameters (such as O 2 content, sulphur or nitrogen content in the feed/fuel), calculations and periodic stack measurements. The use of emission ratios based on S content in the fuel is one example of indirect monitoring. Another example of indirect monitoring is the use of PEMS

9 L 307/46 Term used Definition Predictive Emissions monitoring system (PEMS) Volatile liquid hydrocarbon compounds Recovery rate System to determine the emissions concentration of a pollutant based on its relationship with a number of characteristic continuously monitored process parameters (e.g. fuel-gas consumption, air/fuel ratio) and fuel or feed quality data (e.g. the sulphur content) of an emission source Petroleum derivatives with a Reid vapour pressure (RVP) of more than 4 kpa, such as naphtha and aromatics Percentage of NMVOC recovered from the streams conveyed into a vapour recovery unit (VRU) 1.1. General BAT conclusions for the refining of mineral oil and gas The process-specific BAT conclusions included in Sections 1.2 to 1.19 apply in addition to the general BAT conclusions mentioned in this section Environmental management systems BAT 1. In order to improve the overall environmental performance of plants for the refining of mineral oil and gas, BAT is to implement and adhere to an environmental management system (EMS) that incorporates all of the following features: (i) (ii) (iii) (iv) commitment of the management, including senior management; definition of an environmental policy that includes the continuous improvement for the installation by the management; planning and establishing the necessary procedures, objectives and targets, in conjunction with financial planning and investment; implementation of the procedures paying particular attention to: (a) structure and responsibility (b) training, awareness and competence (c) communication (d) employee involvement (e) documentation (f) efficient process control (g) maintenance programmes (h) emergency preparedness and response (i) safeguarding compliance with environmental legislation. (v) checking performance and taking corrective action, paying particular attention to: (a) monitoring and measurement (see also the reference document on the General Principles of Monitoring) (b) corrective and preventive action (c) maintenance of records (d) independent (where practicable) internal and external auditing in order to determine whether or not the EMS conforms to planned arrangements and has been properly implemented and maintained;

10 L 307/47 (vi) review of the EMS and its continuing suitability, adequacy and effectiveness by senior management; (vii) following the development of cleaner technologies; (viii) consideration for the environmental impacts from the eventual decommissioning of the installation at the stage of designing a new plant, and throughout its operating life; (ix) application of sectoral benchmarking on a regular basis. Applicability The scope (e.g. level of detail) and nature of the EMS (e.g. standardised or non-standardised) will generally be related to the nature, scale and complexity of the installation, and the range of environmental impacts it may have Energy efficiency BAT 2. In order to use energy efficiently, BAT is to use an appropriate combination of the techniques given below. Technique Description (i) Design techniques a. Pinch analysis Methodology based on a systematic calculation of thermodynamic targets for minimising energy consumption of processes. Used as a tool for the evaluation of total systems designs b. Heat integration Heat integration of process systems ensures that a substantial proportion of the heat required in various processes is provided by exchanging heat between streams to be heated and streams to be cooled c. Heat and power recovery Use of energy recovery devices e.g.: waste heat boilers expanders/power recovery in the FCC unit use of waste heat in district heating (ii) Process control and maintenance techniques a. Process optimisation Automated controlled combustion in order to lower the fuel consumption per tonne of feed processed, often combined with heat integration for improving furnace efficiency b. Management and reduction of steam consumption Systematic mapping of drain valve systems in order to reduce steam consumption and optimise its use c. Use of energy benchmark Participation in ranking and benchmarking activities in order to achieve continuous improvement by learning from best practice (iii) Energy-efficient production techniques a. Use of combined heat and power b. Integrated gasification combined cycle (IGCC) System designed for the co-production (or the cogeneration) of heat (e.g. steam) and electric power from the same fuel Technique whose purpose is to produce steam, hydrogen (optional) and electric power from a variety of fuel types (e.g. heavy fuel oil or coke) with a high conversion efficiency

11 L 307/ Solid materials storage and handling BAT 3. In order to prevent or, where that is not practicable, to reduce dust emissions from the storage and handling of dusty materials, BAT is to use one or a combination of the techniques given below: (i) store bulk powder materials in enclosed silos equipped with a dust abatement system (e.g. fabric filter); (ii) store fine materials in enclosed containers or sealed bags; (iii) keep stockpiles of coarse dusty material wetted, stabilise the surface with crusting agents, or store under cover in stockpiles; (iv) use road cleaning vehicles Monitoring of emissions to air and key process parameters BAT 4. BAT is to monitor emissions to air by using the monitoring techniques with at least the minimum frequency given below and in accordance with standards. If standards are not available, BAT is to use ISO, national or other international standards that ensure the provision of data of an equivalent scientific quality. Description Unit Minimum frequency Monitoring technique (i) SO X, NO X, and dust emissions Catalytic cracking Continuous ( 1 ) ( 2 ) Direct measurement Combustion units 100 MW ( 3 ) and calcining units Continuous ( 1 ) ( 2 ) Direct measurement ( 4 ) Combustion units of 50 to 100 MW ( 3 ) Continuous ( 1 ) ( 2 ) Direct measurement or indirect monitoring Combustion units < 50 MW ( 3 ) Once a year and after significant fuel changes ( 5 ) Direct measurement or indirect monitoring Sulphur recovery units (SRU) Continuous for SO 2 only Direct measurement or indirect monitoring ( 6 ) (ii) NH 3 emissions All units equipped with SCR or SNCR Continuous Direct measurement (iii) CO emissions Catalytic cracking and combustion units 100 MW ( 3 ) Continuous Direct measurement Other combustion units Once every 6 months ( 5 ) Direct measurement (iv) Metals emissions: Nickel (Ni), Antimony (Sb) ( 7 ), Vanadium (V) Catalytic cracking Combustion units ( 8 ) Once every 6 months and after significant changes to the unit ( 5 ) Direct measurement or analysis based on metals content in the catalyst fines and in the fuel

12 L 307/49 Description Unit Minimum frequency Monitoring technique (v) Polychlorinated dibenzodioxins/ furans (PCDD/F) emissions Catalytic reformer Once a year or once a regeneration, whichever is longer Direct measurement ( 1 ) Continuous measurement of SO 2 emissions may be replaced by calculations based on measurements of the sulphur content of the fuel or the feed; where it can be demonstrated that this leads to an equivalent level of accuracy. ( 2 ) Regarding SO X, only SO 2 is continuously measured, while SO 3 is only periodically measured (e.g. during calibration of the SO 2 monitoring system). ( 3 ) Refers to the total rated thermal input of all combustion units connected to the stack where emissions occur. ( 4 ) Or indirect monitoring of SO X. ( 5 ) Monitoring frequencies may be adapted if, after a period of one year, the data series clearly demonstrate a sufficient stability. ( 6 ) SO 2 emissions measurements from SRU may be replaced by a continuous material balance or other relevant process parameter monitoring, provided appropriate measurements of SRU efficiency are based on periodic (e.g. once every 2 years) plant performance tests. ( 7 ) Antimony (Sb) is monitored only in catalytic cracking units when Sb injection is used in the process (e.g. for metals passivation). ( 8 ) With the exception of combustion units firing only gaseous fuels. BAT 5. BAT is to monitor the relevant process parameters linked to pollutant emissions, at catalytic cracking and combustion units by using appropriate techniques and with at least the frequency given below. Description Monitoring of parameters linked to pollutant emissions, e.g. O 2 content in flue-gas, N and S content in fuel or feed ( 1 ) Minimum frequency Continuous for O 2 content. For N and S content, periodic at a frequency based on significant fuel/feed changes ( 1 ) N and S monitoring in fuel or feed may not be necessary when continuous emission measurements of NO X and SO 2 are carried out at the stack. BAT 6. BAT is to monitor diffuse VOC emissions to air from the entire site by using all of the following techniques: (i) sniffing methods associated with correlation curves for key equipment; (ii) optical gas imaging techniques; (iii) calculations of chronic emissions based on emissions factors periodically (e.g. once every two years) validated by measurements. The screening and quantification of site emissions by periodic campaigns with optical absorption-based techniques, such as differential absorption light detection and ranging (DIAL) or solar occultation flux (SOF) is a useful complementary technique. Description See Section Operation of waste gas treatment systems BAT 7. In order to prevent or reduce emissions to air, BAT is to operate the acid gas removal units, sulphur recovery units and all other waste gas treatment systems with a high availability and at optimal capacity.

13 L 307/50 Description Special procedures can be defined for other than normal operating conditions, in particular: (i) (ii) during start-up and shutdown operations; during other circumstances that could affect the proper functioning of the systems (e.g. regular and extraordinary maintenance work and cleaning operations of the units and/or of the waste gas treatment system); (iii) in case of insufficient waste gas flow or temperature which prevents the use of the waste gas treatment system at full capacity. BAT 8. In order to prevent and reduce ammonia (NH 3 ) emissions to air when applying selective catalytic reduction (SCR) or selective non-catalytic reduction (SNCR) techniques, BAT is to maintain suitable operating conditions of the SCR or SNCR waste gas treatment systems, with the aim of limiting emissions of unreacted NH 3. BAT-associated emission levels: See Table 2. Table 2 BAT-associated emission levels for ammonia (NH 3 ) emissions to air for a combustion or process unit where SCR or SNCR techniques are used Parameter BAT-AEL z(monthly average) mg/nm 3 Ammonia expressed as NH 3 < 5 15 ( 1 ) ( 2 ) ( 1 ) The higher end of the range is associated with higher inlet NO X concentrations, higher NO X reduction rates and the ageing of the catalyst. ( 2 ) The lower end of the range is associated with the use of the SCR technique. BAT 9. In order to prevent and reduce emissions to air when using a sour water steam stripping unit, BAT is to route the acid off-gases from this unit to an SRU or any equivalent gas treatment system. It is not BAT to directly incinerate the untreated sour water stripping gases Monitoring of emissions to water BAT 10. BAT is to monitor emissions to water by using the monitoring techniques with at least the frequency given in Table 3) and in accordance with standards. If standards are not available, BAT is to use ISO, national or other international standards that ensure the provision of data of an equivalent scientific quality Emissions to water BAT 11. In order to reduce water consumption and the volume of contaminated water, BAT is to use all of the techniques given below. (i) Water stream integration Reduction of process water produced at the unit level prior to discharge by the internal reuse of water streams from e.g. cooling, condensates, especially for use in crude desalting for new units. For existing units, applicability may require a complete rebuilding of the unit or the installation

14 L 307/51 (ii) Water and drainage system for segregation of contaminated water streams Design of an industrial site to optimise water management, where each stream is treated as appropriate, by e.g. routing generated sour water (from distillation, cracking, coking units, etc.) to appropriate pretreatment, such as a stripping unit for new units. For existing units, applicability may require a complete rebuilding of the unit or the installation (iii) Segregation of noncontaminated water streams (e.g. oncethrough cooling, rain water) Design of a site in order to avoid sending non-contaminated water to general waste water treatment and to have a separate release after possible reuse for this type of stream for new units. For existing units, applicability may require a complete rebuilding of the unit or the installation (iv) Prevention of spillages and leaks Practices that include the utilisation of special procedures and/or temporary equipment to maintain performances when necessary to manage special circumstances such as spills, loss of containment, etc. BAT 12. In order to reduce the emission load of pollutants in the waste water discharge to the receiving water body, BAT is to remove insoluble and soluble polluting substances by using all of the techniques given below. (i) Removal of insoluble substances by recovering oil See Section (ii) Removal of insoluble substances by recovering suspended solids and dispersed oil See Section (iii) Removal of soluble substances including biological treatment and clarification See Section BAT-associated emission levels: See Table 3. BAT 13. When further removal of organic substances or nitrogen is needed, BAT is to use an additional treatment step as described in Section Table 3 BAT-associated emission levels for direct waste water discharges from the refining of mineral oil and gas and monitoring frequencies associated with BAT ( 1 ) Parameter Unit BAT-AEL (yearly average) Monitoring ( 2 ) frequency and analytical method (standard) Hydrocarbon oil index (HOI) mg/l 0,1-2,5 Daily ( 3 ) Total suspended solids (TSS) mg/l 5-25 Daily Chemical oxygen demand (COD) ( 4 ) mg/l Daily

15 L 307/52 Parameter Unit BAT-AEL (yearly average) Monitoring ( 2 ) frequency and analytical method (standard) BOD 5 mg/l No BAT-AEL Weekly Total nitrogen ( 5 ), expressed as N mg/l 1-25 ( 6 ) Daily Lead, expressed as Pb mg/l 0,005-0,030 Quarterly Cadmium, expressed as Cd mg/l 0,002-0,008 Quarterly Nickel, expressed as Ni mg/l 0,005-0,100 Quarterly Mercury, expressed as Hg mg/l 0,0001-0,001 Quarterly Vanadium mg/l No BAT-AEL Quarterly Phenol Index mg/l No BAT-AEL Monthly Benzene, toluene, ethyl benzene, xylene (BTEX) mg/l Benzene: 0,001-0,050 No BAT-AEL for T, E, X Monthly ( 1 ) Not all parameters and sampling frequencies are applicable to effluent from gas refining sites. ( 2 ) Refers to a flow-proportional composite sample taken over a period of 24 hours or, provided that sufficient flow stability is demonstrated, a time-proportional sample. ( 3 ) Moving from the current method to may require an adaptation period. ( 4 ) Where on-site correlation is available, COD may be replaced by TOC. The correlation between COD and TOC should be elaborated on a case-by-case basis. TOC monitoring would be the preferred option because it does not rely on the use of very toxic compounds. ( 5 ) Where total-nitrogen is the sum of total Kjeldahl nitrogen (TKN), nitrates and nitrites. ( 6 ) When nitrification/denitrification is used, levels below 15 mg/l can be achieved Waste generation and management BAT 14. In order to prevent or, where that is not practicable, to reduce waste generation, BAT is to adopt and implement a waste management plan that, in order of priority, ensures that waste is prepared for reuse, recycling, recovery or disposal. BAT 15. In order to reduce the amount of sludge to be treated or disposed of, BAT is to use one or a combination of the techniques given below. (i) Sludge pretreatment Prior to final treatment (e.g. in a fluidised bed incinerator), the sludges are dewatered and/or de-oiled (by e.g. centrifugal decanters or steam dryers) to reduce their volume and to recover oil from slop equipment (ii) Reuse of sludge in process units Certain types of sludge (e.g. oily sludge) can be processed in units (e.g. coking) as part of the feed due to their oil content Applicability is restricted to sludges that can fulfil the requirements to be processed in units with appropriate treatment

16 L 307/53 BAT 16. In order to reduce the generation of spent solid catalyst waste, BAT is to use one or a combination of the techniques given below. Technique Description (i) Spent solid catalyst management Scheduled and safe handling of the materials used as catalyst (e.g. by contractors) in order to recover or reuse them in off-site facilities. These operations depend on the type of catalyst and process (ii) Removal of catalyst from slurry decant oil Decanted oil sludge from process units (e.g. FCC unit) can contain significant concentrations of catalyst fines. These fines need to be separated prior to the reuse of decant oil as a feedstock Noise BAT 17. In order to prevent or reduce noise, BAT is to use one or a combination of the techniques given below: (i) make an environmental noise assessment and formulate a noise management plan as appropriate to the local environment; (ii) enclose noisy equipment/operation in a separate structure/unit; (iii) use embankments to screen the source of noise; (iv) use noise protection walls BAT conclusions for integrated refinery management BAT 18. In order to prevent or reduce diffuse VOC emissions, BAT is to apply the techniques given below. I. Techniques related to plant design (i) limiting the number of potential emission sources (ii) maximising inherent process containment features (iii) selecting high integrity equipment (iv) facilitating monitoring and maintenance activities by ensuring access to potentially leaking components Applicability may be limited for existing units II. Techniques related to plant installation and commissioning (i) well-defined procedures for construction and assembly (ii) robust commissioning and hand-over procedures to ensure that the plant is installed in line with the design requirements Applicability may be limited for existing units III. Techniques related to plant operation Use of a risk-based leak detection and repair (LDAR) programme in order to identify leaking components, and to repair these leaks. See Section

17 L 307/ BAT conclusions for the alkylation process Hydrofluoric acid alkylation process BAT 19. In order to prevent hydrofluoric acid (HF) emissions to air from the hydrofluoric acid alkylation process, BAT is to use wet scrubbing with alkaline solution to treat incondensable gas streams prior to venting to flare. Description See Section Applicability: The technique is generally applicable. Safety requirements, due to the hazardous nature of hydrofluoric acid, are to be considered BAT 20. In order to reduce emissions to water from the hydrofluoric acid alkylation process, BAT is to use a combination of the techniques given below. (i) Precipitation/Neutralisation step Precipitation (with, e.g. calcium or aluminium-based additives) or neutralisation (where the effluent is indirectly neutralised with potassium hydroxide (KOH)). Safety requirements due to the hazardous nature of hydrofluoric acid (HF) are to be considered (ii) Separation step The insoluble compounds produced at the first step (e.g. CaF 2 or AlF 3 ) are separated in e.g. a settlement basin Sulphuric acid alkylation process BAT 21. In order to reduce the emissions to water from the sulphuric acid alkylation process, BAT is to reduce the use of sulphuric acid by regenerating the spent acid and to neutralise the waste water generated by this process before routing to waste water treatment BAT conclusions for base oil production processes BAT 22. In order to prevent and reduce the emissions of hazardous substances to air and water from base oil production processes, BAT is to use one or a combination of the techniques given below. (i) Closed process with a solvent recovery Process where the solvent, after being used during base oil manufacturing (e.g. in extraction, dewaxing units), is recovered through distillation and stripping steps. See Section (ii) Multi-effect extraction solvent-based process Solvent extraction process including several stages of evaporation (e.g. double or triple effect) for a lower loss of containment to new units. The use of a triple effect process may be restricted to non-fouling feed stocks

18 L 307/55 (iii) Extraction unit processes using less hazardous substances Design (new plants) or implement changes (into existing) so that the plant operates a solvent extraction process with the use of a less hazardous solvent: e.g. converting furfural or phenol extraction into the n-methylpyrrolidone (NMP) process to new units. Converting existing units to another solvent-based process with different physico-chemical properties may require substantial modifications (iv) Catalytic processes based on hydrogenation Processes based on conversion of undesired compounds via catalytic hydrogenation similar to hydrotreatment. See Section (Hydrotreatment) to new units 1.4. BAT conclusions for the bitumen production process BAT 23. In order to prevent and reduce emissions to air from the bitumen production process, BAT is to treat the gaseous overhead by using one of the techniques given below. (i) Thermal oxidation of gaseous overhead over 800 C See Section for the bitumen blowing unit (ii) Wet scrubbing of gaseous overhead See Section for the bitumen blowing unit 1.5. BAT conclusions for the fluid catalytic cracking process BAT 24. In order to prevent or reduce NO X emissions to air from the catalytic cracking process (regenerator), BAT is to use one or a combination of the techniques given below. I. Primary or process-related techniques, such as: Process optimisation and use of promoters or additives (i) Process optimisation Combination of operating conditions or practices aimed at reducing NO X formation, e.g. lowering the excess oxygen in the flue-gas in full combustion mode, air staging of the CO boiler in partial combustion mode, provided that the CO boiler is appropriately designed (ii) Low-NO X CO oxidation promoters Use of a substance that selectively promotes the combustion of CO only and prevents the oxidation of the nitrogen that contains intermediates to NO X : e.g. non-platinum promoters Applicable only in full combustion mode for the substitution of platinum-based CO promoters. Appropriate distribution of air in the regenerator may be required to obtain the maximum benefit

19 L 307/56 (iii) Specific additives for NO X reduction Use of specific catalytic additives for enhancing the reduction of NO by CO Applicable only in full combustion mode in an appropriate design and with achievable oxygen excess. The applicability of copper-based NO X reduction additives may be limited by the gas compressor capacity II. Secondary or end-of-pipe techniques, such as: (i) Selective catalytic reduction (SCR) See Section To avoid potential fouling downstream, additional filtering might be required upstream of the SCR. For existing units, the applicability may be limited by space availability (ii) Selective non-catalytic reduction (SNCR) See Section For partial combustion FCCs with CO boilers, a sufficient residence time at the appropriate temperature is required. For full combustion FCCs without auxiliary boilers, additional fuel injection (e.g. hydrogen) may be required to match a lower temperature window (iii) Low temperature oxidation See Section Need for additional scrubbing capacity. Ozone generation and the associated risk management need to be properly addressed. The applicability may be limited by the need for additional waste water treatment and related cross-media effects (e.g. nitrate emissions) and by an insufficient supply of liquid oxygen (for ozone generation). The applicability of the technique may be limited by space availability BAT-associated emission levels: See Table 4. Table 4 BAT-associated emission levels for NO X emissions to air from the regenerator in the catalytic cracking process Parameter Type of unit/combustion mode BAT-AEL (monthly average) mg/nm 3 NO X, expressed as NO 2 New unit/all combustion mode < Existing unit/full combustion mode < ( 1 ) Existing unit/partial combustion mode ( 1 ) ( 1 ) When antimony (Sb) injection is used for metal passivation, NO X levels up to 700 mg/nm 3 may occur. The lower end of the range can be achieved by using the SCR technique.

20 L 307/57 The associated monitoring is in BAT 4. BAT 25. In order to reduce dust and metals emissions to air from the catalytic cracking process (regenerator), BAT is to use one or a combination of the techniques given below. I. Primary or process-related techniques, such as: (i) Use of an attrition-resistant catalyst Selection of catalyst substance that is able to resist abrasion and fragmentation in order to reduce dust emissions provided the activity and selectivity of the catalyst are sufficient (ii) Use of low sulphur feedstock (e.g. by feedstock selection or by hydrotreatment of feed) Feedstock selection favours low sulphur feedstocks among the possible sources to be processed at the unit. Hydrotreatment aims at reducing the sulphur, nitrogen and metal contents of the feed. See Section Requires sufficient availability of low sulphur feedstocks, hydrogen production and hydrogen sulphide (H 2 S) treatment capacity (e.g. amine and Claus units) II. Secondary or end-of-pipe techniques, such as: (i) Electrostatic precipitator (ESP) See Section For existing units, the applicability may be limited by space availability (ii) Multistage cyclone separators See Section (iii) Third stage blowback filter See Section Applicability may be restricted (iv) Wet scrubbing See Section The applicability may be limited in arid areas and in the case where the by-products from treatment (including e.g. waste water with high level of salts) cannot be reused or appropriately disposed of. For existing units, the applicability may be limited by space availability BAT-associated emission levels: See Table 5. Table 5 BAT-associated emission levels for dust emissions to air from the regenerator in the catalytic cracking process Parameter Type of unit BAT-AEL (monthly average) ( 1 ) mg/nm 3 Dust New unit ( 1 ) Soot blowing in CO boiler and through the gas cooler is excluded. ( 2 ) The lower end of the range can be achieved with a 4-field ESP. Existing unit ( 2 )

21 L 307/58 The associated monitoring is in BAT 4. BAT 26. In order to prevent or reduce SO X emissions to air from the catalytic cracking process (regenerator), BAT is to use one or a combination of the techniques given below. I. Primary or process-related techniques, such as: (i) Use of SO X reducing catalyst additives Use of a substance that transfers the sulphur associated with coke from the regenerator back to the reactor. See description in Applicability may be restricted by regenerator conditions design. Requires appropriate hydrogen sulphide abatement capacity (e.g. SRU) (ii) Use of low sulphur feedstock (e.g. by feedstock selection or by hydrotreatment of the feed) Feedstock selection favours low sulphur feedstocks among the possible sources to be processed at the unit. Hydrotreatment aims at reducing the sulphur, nitrogen and metal contents of the feed. See description in Requires sufficient availability of low sulphur feedstocks, hydrogen production and hydrogen sulphide (H 2 S) treatment capacity (e.g. amine and Claus units) II. Secondary or end-of-pipe techniques, such as: Techniques Description Applicability (i) Non-regenerative scrubbing Wet scrubbing or seawater scrubbing. See Section The applicability may be limited in arid areas and in the case where the by-products from treatment (including e.g. waste water with high level of salts) cannot be reused or appropriately disposed of. For existing units, the applicability may be limited by space availability (ii) Regenerative scrubbing Use of a specific SO X absorbing reagent (e.g. absorbing solution) which generally enables the recovery of sulphur as a byproduct during a regenerating cycle where the reagent is reused. See Section The applicability is limited to the case where regenerated by-products can be sold. For existing units, the applicability may be limited by the existing sulphur recovery capacity as well as by space availability BAT-associated emission levels: See Table 6.

22 L 307/59 Table 6 BAT-associated emission levels for SO 2 emissions to air from the regenerator in the catalytic cracking process Parameter Type of units/mode BAT-AEL (monthly average) mg/nm 3 SO 2 New units 300 Existing units/full combustion < ( 1 ) Existing units/partial combustion ( 1 ) ( 1 ) Where selection of low sulphur (e.g. < 0,5 % w/w) feed (or hydrotreatment) and/or scrubbing is applicable, for all combustion modes: the upper end of the BAT-AEL range is 600 mg/nm 3. The associated monitoring is in BAT 4. BAT 27. In order to reduce carbon monoxide (CO) emissions to air from the catalytic cracking process (regenerator), BAT is to use one or a combination of the techniques given below. (i) Combustion operation control See Section (ii) Catalysts with carbon monoxide (CO) oxidation promoters See Section only for full combustion mode (iii) Carbon monoxide (CO) boiler See Section only for partial combustion mode BAT-associated emission levels: See Table 7. Table 7 BAT-associated emission levels for carbon monoxide emissions to air from the regenerator in the catalytic cracking process for partial combustion mode Parameter Combustion mode BAT-AEL (monthly average) mg/nm 3 Carbon monoxide, expressed as CO Partial combustion mode 100 ( 1 ) ( 1 ) May not be achievable when not operating the CO boiler at full load. The associated monitoring is in BAT BAT conclusions for the catalytic reforming process BAT 28. In order to reduce emissions of polychlorinated dibenzodioxins/furans (PCDD/F) to air from the catalytic reforming unit, BAT is to use one or a combination of the techniques given below.

23 L 307/60 (i) Choice of the catalyst promoter Use of catalyst promoter in order to minimise polychlorinated dibenzodioxins/furans (PCDD/F) formation during regeneration. See Section (ii) Treatment of the regeneration flue-gas a. Regeneration gas recycling loop with adsorption bed Waste gas from the regeneration step is treated to remove chlorinated compounds (e.g. dioxins) to new units. For existing units the applicability may depend on the current regeneration unit design b. Wet scrubbing See Section Not applicable to semi-regenerative reformers c. Electrostatic precipitator (ESP) See Section Not applicable to semi-regenerative reformers 1.7. BAT conclusions for the coking processes BAT 29. In order to reduce emissions to air from the coking production processes, BAT is to use one or a combination of the techniques given below: Primary or process-related techniques, such as: (i) Collection and recycling of coke fines Systematic collection and recycling of coke fines generated during the whole coking process (drilling, handling, crushing, cooling, etc.) (ii) Handling and storage of coke according to BAT 3 See BAT 3 (iii) Use of a closed blowdown system Arrestment system for pressure relief from the coke drums (iv) Recovery of gas (including the venting prior to the drum being opened to atmosphere) as a component of refinery fuel gas (RFG) Carrying venting from the coke drum to the gas compressor to recover as RFG, rather than flaring. For the flexicoking process, a conversion step (to convert the carbonyl sulphide (COS) into H 2 S) is needed prior to treating the gas from the coking unit For existing units, the applicability of the techniques may be limited by space availability BAT 30. In order to reduce NO X emissions to air from the calcining of green coke process, BAT is to use selective non-catalytic reduction (SNCR).

24 L 307/61 Description See Section Applicability The applicability of the SNCR technique (especially with respect to residence time and temperature window) may be restricted due to the specificity of the calcining process. BAT 31. In order to reduce SO X emissions to air from the calcining of green coke process, BAT is to use one or a combination of the techniques given below. (i) Non-regenerative scrubbing Wet scrubbing or seawater scrubbing. See Section The applicability may be limited in arid areas and in the case where the by-products from treatment (including e.g. waste water with high level of salts) cannot be reused or appropriately disposed of. For existing units, the applicability may be limited by space availability (ii) Regenerative scrubbing Use of a specific SO X absorbing reagent (e.g. absorbing solution) which generally enables the recovery of sulphur as a byproduct during a regenerating cycle where the reagent is reused. See Section The applicability is limited to the case where regenerated by-products can be sold. For existing units, the applicability may be limited by the existing sulphur recovery capacity as well as by space availability BAT 32. In order to reduce dust emissions to air from the calcining of green coke process, BAT is to use a combination of the techniques given below. (i) Electrostatic precipitator (ESP) See Section For existing units, the applicability may be limited by space availability. For graphite and anode coke calcining production, the applicability may be restricted due to the high resistivity of the coke particles (ii) Multistage cyclone separators See Section BAT-associated emission levels: See Table 8 Table 8 BAT-associated emission levels for dust emissions to air from a unit for the calcining of green coke Parameter BAT-AEL (monthly average) mg/nm 3 Dust ( 1 ) ( 2 ) ( 1 ) The lower end of the range can be achieved with a 4-field ESP. ( 2 ) When an ESP is not applicable, values of up to 150 mg/nm 3 may occur.